“Diamondback remains committed to capital discipline by continuing to grow production at industry leading rates within cash flow and achieving an annualized return on average capital employed of over 13% in the first quarter, well above our estimated cost of capital. The execution of our forward operating plan while maintaining best in class operating metrics is the primary focus of our organization in an increasingly active Permian Basin,” stated Travis Stice, Chief Executive Officer of Diamondback.

Mr. Stice continued, “We have made significant progress on our Permian Basin takeaway strategy, with the 50,000 barrel per day commitment to the Gray Oak Pipeline being the first step of many as we work to increase our exposure to international pricing away from the Midland market. Additionally, Diamondback will continue to be active, yet selective, in our acquisition strategy, with accretion and full-cycle economics remaining key drivers of our decision making process. Our disciplined approach to all facets of the business, from day-to-day operations to longer-term strategic decisions, is evidenced by Diamondback’s significant Adjusted EBITDA per share growth since going public just over five years ago.”

OPERATIONAL HIGHLIGHTS

Diamondback’s Q1 2018 production was 102.6 Mboe/d (74% oil), up 67% year over year from 61.6 Mboe/d in Q1 2017, and up over 10% quarter over quarter from 92.9 Mboe/d in Q4 2017.

During the first quarter of 2018, Diamondback drilled 41 gross horizontal wells and turned 35 operated horizontal wells to production. The average completed lateral length for first quarter wells was 9,000 feet. Operated completions during the first quarter consisted of 20 Wolfcamp A wells, nine Lower Spraberry wells, four Wolfcamp B wells, one Middle Spraberry well and one Third Bone Spring shale well. The Company operated 10 drilling rigs and four dedicated frac spreads during the quarter.

The Company is currently operating 11 horizontal rigs and five dedicated frac crews, and plans to operate, on average, between 10 and 12 horizontal rigs throughout 2018. As a result, Diamondback expects to turn between 170 and 190 gross operated horizontal wells to production for the full year 2018.

OPERATIONS UPDATE

In Pecos County, Diamondback continues to see strong performance from operated completions targeting the Wolfcamp A. After achieving a peak 30-day 2-stream flowing initial production (“IP”) rate of 226 boe/d per 1,000 feet (91% oil), the State Biggs 12A-2 2WA went on to achieve a peak 90-day flowing IP rate of 172 boe/d per 1,000 feet (91% oil). Subsequently in the first quarter, Diamondback completed another Wolfcamp A well with a 7,527 foot lateral. This well, the Neal Lethco 39-37 Unit 2WA, achieved a peak 30-day flowing IP rate of 159 boe/d per 1,000 feet (84% oil) and a peak 60-day flowing IP rate of 141 boe/d per 1,000 feet (84% oil).

In Reeves County, Diamondback recently completed its first well targeting the Third Bone Spring shale with a 9,401 foot lateral. This well, the Rogers 6 Unit 3TB, achieved a peak 30-day flowing IP rate of 122 boe/d per 1,000 feet (80% oil), and went on to achieve a peak 90-day flowing IP rate of 110 boe/d per 1,000 feet (81% oil).

In the Midland Basin, the Company recently completed a four-well pad in Midland County targeting the Lower Spraberry and Wolfcamp A with an average lateral length of 10,353 feet. Two Wolfcamp A wells on the Bombardier C Unit pad achieved an average 30-day IP rate of 134 boe/d per 1,000 feet (89% oil), while two Lower Spraberry wells averaged 123 boe/d per 1,000 feet (88% oil) over the same period.

In Glasscock County, Diamondback has drilled and completed a seven-well pad targeting the Wolfcamp A and Wolfcamp B with an average lateral length of 9,984 feet. The initial two Wolfcamp A completions achieved an average 30-day IP rate of 117 boe/d per 1,000 feet (86% oil), while the initial Wolfcamp B well produced 143 boe/d per 1,000 feet (85% oil) over the same period. The remaining four wells are still flowing back.

FINANCIAL HIGHLIGHTS

Diamondback’s first quarter 2018 net income was $163 million, or $1.65 per diluted share. Adjusted net income (a non-GAAP financial measure as defined and reconciled below) was $162 million, or $1.64 per diluted share.

First quarter 2018 Adjusted EBITDA (as defined and reconciled below) was $341 million, up 13% from $302 million in Q4 2017.

First quarter 2018 average realized prices were $61.66 per barrel of oil, $2.20 per Mcf of natural gas and $24.64 per barrel of natural gas liquids, resulting in a total equivalent unhedged price of $50.55/boe, up 12% from $45.31/boe in Q4 2017.

Diamondback’s cash operating costs for the first quarter 2018 were $8.42 per boe, including lease operating expenses (“LOE”) of $4.04 per boe, cash general and administrative expenses of $0.96 per boe and taxes and transportation of $3.42 per boe.

As of March 31, 2018, Diamondback had $54 million in standalone cash and $166 million outstanding on its revolving credit facility. In connection with its Spring 2018 redetermination expected to close in May 2018, the lead bank on Diamondback’s credit facility recommended a borrowing base increase to $2.0 billion from $1.8 billion, while the Company intends to limit the lenders’ aggregate commitment to $1.0 billion. Additionally, Viper Energy Partners LP (“Viper”), a subsidiary of Diamondback, expects to have its borrowing base increased to $475 million from $400 million currently.

During the first quarter of 2018, Diamondback spent $275 million on drilling, completion and non-operated properties, and $43 million on infrastructure and midstream.

DIVIDEND DECLARATION

Diamondback announced today that the Company’s Board of Directors has declared a cash dividend for the first quarter of 12.5 cents per common share payable on May 29, 2018, to shareholders of record at the close of business on May 21, 2018.

FULL YEAR 2018 GUIDANCE

Below is Diamondback’s guidance for the full year 2018, which has been updated to reflect a narrowed production range and lower lease operating expenses per boe.

2018 Guidance

Diamondback Energy, Inc.

Viper Energy Partners LP

Total Net Production – MBoe/d

110.0 – 116.0

15.5 – 16.5

Oil Production – % of Net Production

73% – 76%

71% – 75%

Unit costs ($/boe)

Lease operating expenses, including workovers

$3.75 – $4.50

Gathering & Transportation

$0.25 – $0.50

$0.10 – $0.30

G&A

Cash G&A

Under $1.00

$0.75 – $1.25

Non-cash equity-based compensation

$0.75 – $1.25

$0.75 – $1.25

DD&A

$11.00 – $14.00

$9.00 – $11.00

Interest expense (net of interest income)

$1.00 – $2.00

Production and ad valorem taxes (% of revenue)(a)

7.0%

7.0%

Corporate tax rate (% of pre-tax income)

20% – 23%

Gross horizontal D,C&E/Ft. – Midland Basin

$760 – $810

Gross horizontal D,C&E/Ft. – Delaware Basin

$1,125 – $1,225

Horizontal wells completed (net)

170 – 190 (146 – 163)

Capital Budget ($ – million)

Horizontal drilling and completion

$1,175 – $1,325

Infrastructure

$125 – $175

2018 Capital Spend

$1,300 – $1,500

(a) Includes production taxes of 4.6% for crude oil and 7.5% for natural gas and NGLs and ad valorem taxes.

CONFERENCE CALL

Diamondback will host a conference call and webcast for investors and analysts to discuss its results for the first quarter of 2018 on Wednesday, May 9, 2018 at 9:00 a.m. CT. Participants should call (877) 440-7573 (United States/Canada) or (253) 237-1144 (International) and use the confirmation code 7478817. A telephonic replay will be available from 12:00 p.m. CT on Wednesday, May 9, 2018 through Wednesday, May 16, 2018 at 12:00 p.m. CT. To access the replay, call (855) 859-2056 (United States/Canada) or (404) 537-3406 (International) and enter confirmation code 7478817. A live broadcast of the earnings conference call will also be available via the internet at www.diamondbackenergy.com under the “Investor Relations” section of the site. A replay will also be available on the website following the call.

About Diamondback Energy, Inc.

Diamondback is an independent oil and natural gas Company headquartered in Midland, Texas focused on the acquisition, development, exploration and exploitation of unconventional, onshore oil and natural gas reserves in the Permian Basin in West Texas. Diamondback’s activities are primarily focused on the horizontal exploitation of multiple intervals within the Wolfcamp, Spraberry, Clearfork, Bone Spring and Cline formations.

Forward Looking Statements

This news release contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. All statements, other than historical facts, that address activities that Diamondback assumes, plans, expects, believes, intends or anticipates (and other similar expressions) will, should or may occur in the future are forward-looking statements. The forward-looking statements are based on management’s current beliefs, based on currently available information, as to the outcome and timing of future events. These forward-looking statements involve certain risks and uncertainties that could cause the results to differ materially from those expected by the management of Diamondback. Information concerning these risks and other factors can be found in Diamondback’s filings with the Securities and Exchange Commission, including its Forms 10-K, 10-Q and 8-K, which can be obtained free of charge on the Securities and Exchange Commission’s web site at http://www.sec.gov. Diamondback undertakes no obligation to update or revise any forward-looking statement.

Diamondback Energy, Inc.

Consolidated Statements of Operations

(unaudited, in thousands, except share amounts and per share data)

Three Months Ended
March 31,

2018

2017

Revenues

Oil, natural gas and natural gas liquids

$

466,759

$

232,498

Lease bonus

—

1,602

Midstream services

11,395

1,130

Other operating income

2,041

—

Total revenues

480,195

235,230

Operating expenses

Lease operating expenses

37,345

26,626

Production and ad valorem taxes

27,304

15,725

Gathering and transportation

4,285

2,619

Midstream services

11,189

854

Depreciation, depletion and amortization

115,216

58,929

General and administrative expenses(1)

16,325

13,744

Asset retirement obligation accretion

355

323

Other operating expense

530

—

Total expenses

212,549

118,820

Income from operations

267,646

116,410

Interest expense, net

(13,701

)

(12,225

)

Other income, net

2,736

1,145

Gain (loss) on derivative instruments, net

(32,345

)

37,701

Gain on revaluation of investment

899

—

Total other income (expense), net

(42,411

)

26,621

Income before income taxes

225,235

143,031

Provision for income taxes

47,081

1,957

Net income

178,154

141,074

Net income attributable to non-controlling interest

15,342

4,801

Net income attributable to Diamondback Energy, Inc.

$

162,812

$

136,273

Earnings per common share:

Basic

$

1.65

$

1.46

Diluted

$

1.65

$

1.46

Weighted average common shares outstanding:

Basic

98,555

93,161

Diluted

98,769

93,364

(1) Includes non-cash expense of $7,451 and $7,063 for the three months ended March 31, 2018 and 2017, respectively.

Diamondback Energy, Inc.

Selected Operating Data

(unaudited)

Three Months

Three Months

Three Months

Ended March 31,

Ended December 31,

Ended March 31,

2018

2017

2017

Production Data:

Oil (MBbl)

6,800

6,345

4,158

Natural gas (MMcf)

6,546

6,103

3,683

Natural gas liquids (MBbls)

1,344

1,182

773

Oil Equivalents (MBOE)(1)(2)

9,235

8,544

5,545

Average daily production (BOE/d)(2)

102,607

92,872

61,610

% Oil

74%

74%

75%

Average sales prices:

Oil, realized ($/Bbl)

$

61.66

$

53.59

$

49.80

Natural gas realized ($/Mcf)

2.20

2.40

2.69

Natural gas liquids ($/Bbl)

24.64

27.43

20.05

Average price realized ($/BOE)

50.55

45.31

41.93

Oil, hedged ($/Bbl)(3)

56.82

52.73

49.40

Natural gas, hedged ($ per MMbtu)(3)

2.29

2.59

2.69

Average price, hedged ($/BOE)(3)

47.05

44.81

41.63

Average Costs per BOE:

Lease operating expense

$

4.04

$

4.50

$

4.80

Production and ad valorem taxes

2.96

2.75

2.84

Gathering and transportation expense

0.46

0.44

0.47

General and administrative – cash component

0.96

0.59

1.20

Total operating expense – cash

$

8.42

$

8.28

$

9.31

General and administrative – non-cash component

$

0.81

$

0.71

$

1.28

Depreciation, depletion and amortization

12.48

12.30

10.63

Interest expense, net

1.48

1.27

2.20

(1) Bbl equivalents are calculated using a conversion rate of six Mcf per one Bbl.
(2) The volumes presented are based on actual results and are not calculated using the rounded numbers in the table above.
(3) Hedged prices reflect the effect of our commodity derivative transactions on our average sales prices. Our calculation of such effects includes realized gains and losses on cash settlements for commodity derivatives, which we do not designate for hedge accounting.

NON-GAAP FINANCIAL MEASURES

Adjusted EBITDA is a supplemental non-GAAP financial measure that is used by management and external users of our financial statements, such as industry analysts, investors, lenders and rating agencies. The Company defines Adjusted EBITDA as net income plus non-cash (gain) loss on derivative instruments, net, net interest expense, net, depreciation, depletion and amortization, non-cash equity-based compensation expense, capitalized equity-based compensation expense, asset retirement obligation accretion expense, gain on revaluation of investment and income tax (benefit) provision. Adjusted EBITDA is not a measure of net income as determined by United States’ generally accepted accounting principles (“GAAP”). Management believes Adjusted EBITDA is useful because it allows it to more effectively evaluate the Company’s operating performance and compare the results of its operations from period to period without regard to its financing methods or capital structure. The Company adds the items listed above to net income in arriving at Adjusted EBITDA because these amounts can vary substantially from company to company within its industry depending upon accounting methods and book values of assets, capital structures and the method by which the assets were acquired. Adjusted EBITDA should not be considered as an alternative to, or more meaningful than, net income as determined in accordance with GAAP or as an indicator of the Company’s operating performance or liquidity. Certain items excluded from Adjusted EBITDA are significant components in understanding and assessing a company’s financial performance, such as a company’s cost of capital and tax structure, as well as the historic costs of depreciable assets, none of which are components of Adjusted EBITDA. Adjusted net income is a non-GAAP financial measure equal to net income attributable to Diamondback Energy, Inc. plus non-cash loss on derivative instruments, gain on revaluation of investment and related income tax adjustments. The Company’s computations of Adjusted EBITDA and adjusted net income may not be comparable to other similarly titled measures of other companies or to such measure in our credit facility or any of our other contracts.

The following tables present a reconciliation of the non-GAAP financial measure of Adjusted EBITDA to the GAAP financial measure of net income (loss).

Diamondback Energy, Inc.

Reconciliation of Adjusted EBITDA to Net Income

(unaudited, in thousands)

Three Months

Three Months

Three Months

Ended March 31,

Ended December 31,

Ended March 31,

2018

2017

2017

Net income (loss)

$

178,154

$

129,607

$

141,074

Non-cash (gain) loss on derivative instruments, net

38

93,605

(39,375

)

Interest expense, net

13,701

10,892

12,225

Depreciation, depletion and amortization

115,216

105,078

58,929

Non-cash equity-based compensation expense

10,092

8,349

9,406

Capitalized equity-based compensation expense

(2,641

)

(2,230

)

(2,343

)

Asset retirement obligation accretion expense

355

361

323

Gain on revaluation of investment

(899

)

—

—

Income tax (benefit) provision

47,081

(23,961

)

1,957

Consolidated Adjusted EBITDA

$

361,097

$

321,701

$

182,196

EBITDA attributable to noncontrolling interest

(20,353

)

(19,815

)

(6,933

)

Adjusted EBITDA attributable to Diamondback Energy, Inc.

$

340,744

$

301,886

$

175,263

Adjusted EBITDA per common share:

Basic

$

3.46

$

3.08

$

1.88

Diluted

$

3.45

$

3.07

$

1.88

Weighted average common shares outstanding:

Basic

98,555

98,169

93,161

Diluted

98,769

98,368

93,364

Adjusted net income is a performance measure used by management to evaluate performance, prior to non-cash loss on derivative instruments, gain on revaluation of investment and related income tax adjustments.

The following table presents a reconciliation of adjusted net income to net income:

Diamondback Energy, Inc.

Adjusted Net Income

(unaudited, in thousands, except share amounts and per share data)

Three Months Ended
March 31, 2018

Pre-Tax
Amounts

Amounts
Per Share

Net income attributable to Diamondback Energy, Inc.

$

162,812

$

1.65

Non-cash loss on derivative instruments

38

—

Gain on revaluation of investments

(899

)

(0.01

)

Adjusted income excluding non-cash loss on derivative instruments and gain on revaluation of investment

161,951

1.64

Income tax adjustment for above items

180

—

Adjusted net income

$

162,131

$

1.64

Derivatives

As of the filing date, the Company had the following outstanding derivative contracts. The Company’s derivative contracts are based upon reported settlement prices on commodity exchanges, with crude oil derivative settlements based on New York Mercantile Exchange West Texas Intermediate pricing and Crude Oil Brent and with natural gas derivative settlements based on the New York Mercantile Exchange Henry Hub pricing. When aggregating multiple contracts, the weighted average contract price is disclosed.